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• Journal article
  Deveugle PEK, Jackson MD, Hampson GJ, Farrell ME, Sprague AR, Stewart J, Calvert CSet al., 2011,

  Characterization of stratigraphic architecture and its impact on fluid flow in a fluvial-dominated deltaic reservoir analog: Upper Cretaceous Ferron Sandstone Member, Utah

  , AAPG Bulletin, Vol: 95, Pages: 693-727, ISSN: 0149-1423

  <jats:title>Abstract</jats:title> <jats:p>Fluviodeltaic stratigraphic architecture and its impact on fluid flow have been characterized using a high-resolution, three-dimensional, reservoir-scale model of an outcrop analog from the Upper Cretaceous Ferron Sandstone Member of central Utah. The model contains two parasequence sets (delta complexes), each with five or six parasequences, separated by an interval of coastal plain strata. Each parasequence contains one or two laterally offset teardrop-shaped delta lobes that are 6 to 12 km (4–7 mi) long, 3 to 9 km (2–6 mi) wide, 5 to 29 m (16–95 ft) thick, and have aspect ratios (width/length) of 0.4 to 0.8. Delta lobes have a wide range of azimuthal orientations (120°) around an overall east-northeastward progradation direction. In plan view, delta lobes in successive parasequences exhibit large (as much as 91°) clockwise and counterclockwise rotations in progradation direction, which are attributed to autogenic lobe switching. In cross-sectional view, parasequence stacking is strongly progradational, but a small component of aggradation or downstepping between parasequences reflects relative sea level fluctuations.</jats:p> <jats:p>We use flow simulations to characterize the impact of this heterogeneity on production in terms of the sweep efficiency, which is controlled by (1) the continuity, orientation, and permeability of channel-fill sand bodies; (2) the vertical permeability of distal delta-front heteroliths; (3) the direction of sweep relative to the orientation of channel-fill and delta-lobe sand bodies; and (4) well spacing. Distributary channel-fill sand bodies terminate at the apex of genetically related delta lobes and provide limited sand body connectivity. In contrast, fluvial channel-fill sand bodies cut into, and connect, multiple delta-lobe sand bodies. Low, but non-zero, vertical permeability within distal delta-fr

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• Journal article
  Choi K, Jackson MD, Hampson GJ, Jones ADW, Reynolds ADet al., 2011,

  Predicting the impact of sedimentological heterogeneity on gas–oil and water–oil displacements: fluvio-deltaic Pereriv Suite Reservoir, Azeri–Chirag–Gunashli Oilfield, South Caspian Basin

  , Petroleum Geoscience, Vol: 17, Pages: 143-163, ISSN: 1354-0793
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• Journal article
  Vinogradov J, 2011,

  Multiphase streaming potential in sandstones saturated with gas/brine and oil/brine during drainage and imbibition

  , Geophysical Research Letters
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• Journal article
  Jackson MD, 2010,

  Multiphase electrokinetic coupling: Insights into the impact of fluid and charge distribution at the pore scale from a bundle of capillary tubes model

  , JOURNAL OF GEOPHYSICAL RESEARCH-SOLID EARTH, Vol: 115, ISSN: 2169-9313
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  • Citations: 87
• Journal article
  TAGGART S, HAMPSON GJ, JACKSON MD, 2010,

  High-resolution stratigraphic architecture and lithological heterogeneity within marginal aeolian reservoir analogues

  , Sedimentology, ISSN: 0037-0746
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• Journal article
  Glover PWJ, Jackson MD, 2010,

  Borehole electrokinetics

  , The Leading Edge, Vol: 29, Pages: 724-728
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• Journal article
  Leinov E, Vinogradov J, Jackson MD, 2010,

  Salinity Dependence of the Thermoelectric Coupling Coefficient in Brine-Saturated Sandstones

  , Geophysical Research Letters
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• Journal article
  Vinogradov J, Jaafar MZ, Jackson MD, 2010,

  Measurement of Streaming Potential Coupling Coefficient in Sandstones Saturated with Natural and Artificial Brines at High Salinity

  , Journal of Geophysical Research
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• Journal article
  Getsinger A, Rushmer T, Jackson MD, Baker Det al., 2009,

  Generating High Mg-numbers and Chemical Diversity in Tonalite-Trondhjemite-Granodiorite (TTG) Magmas during Melting and Melt Segregation in the Continental Crust

  , JOURNAL OF PETROLOGY, Vol: 50, Pages: 1935-1954, ISSN: 0022-3530
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  • Citations: 31
• Journal article
  Sech RP, Jackson MD, Hampson GJ, 2009,

  Three-dimensional modeling of a shoreface-shelf parasequence reservoir analog: Part 1. Surface-based modeling to capture high-resolution facies architecture

  , AAPG Bulletin, Vol: 93, Pages: 1155-1181, ISSN: 0149-1423

  <jats:title>Abstract</jats:title> <jats:p>Conventional reservoir modeling approaches are developed to account for uncertainty associated with sparse subsurface data but are not equipped for detailed reconstruction of high-resolution geologic data sets. We present a surface-based modeling procedure that enables explicit representation of heterogeneity across a hierarchy of length scales. Numerous surfaces are used to construct complex facies-body geometries and distributions prior to generating a grid, allowing sampled and conceptual data to be fully incorporated within field-scale models. Our approach is driven by the improved efficiency that surfaces introduce to reservoir modeling through their geologically intuitive design, rapid construction, and ease of manipulation. Cornerpoint gridding of the architecture defined by the surfaces reduces the number of cells required to represent complex geometries, thus preserving geologic detail and rendering upscaling unnecessary for fluid-flow simulations.</jats:p> <jats:p>The application of surface-based modeling is demonstrated by reconstructing the detailed three-dimensional facies architecture of a wave-dominated shoreface-shelf parasequence from a rich outcrop data set. The studied outcrop data set describes reservoir architecture in a generic analog for many shallow-marine reservoirs. The process of model construction has demonstrated the function of (1) shoreface-shelf clinoforms, (2) paleogeographic changes in shoreline orientation, and (3) storm-event-bed amalgamation in controlling facies architecture. These subtle geometric features cannot be accurately represented using conventional stochastic reservoir modeling algorithms, which results in poor estimation of facies proportions and associated hydrocarbon volumes in place. In contrast, the surface-based modeling approach honors all data and captures subtle geometric facies relationships, thus allowin

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• Journal article
  Jackson MD, Hampson GJ, Sech RP, 2009,

  Three-dimensional modeling of a shoreface-shelf parasequence reservoir analog: Part 2. Geologic controls on fluid flow and hydrocarbon recovery

  , AAPG BULLETIN, Vol: 93, Pages: 1183-1208, ISSN: 0149-1423
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  • Citations: 61
• Journal article
  Jaafar MZ, Vinogradov J, Jackson MD, 2009,

  Measurements of Streaming Potential Coupling Coefficient in Sandstones Saturated with High Salinity NaCl Brine

  , Geophysical Research Letters
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• Journal article
  Jackson MD, 2008,

  Characterization of multiphase electrokinetic coupling using a bundle of capillary tubes model

  , JOURNAL OF GEOPHYSICAL RESEARCH-SOLID EARTH, Vol: 113, ISSN: 2169-9313
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  • Citations: 63
• Journal article
  Jonoud S, Jackson MD, 2008,

  Validity of steady-state upscaling techniques

  , SPE RESERVOIR EVALUATION & ENGINEERING, Vol: 11, Pages: 405-416, ISSN: 1094-6470
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  • Citations: 7
• Journal article
  Jonoud S, Jackson MD, 2008,

  New criteria for the validity of steady-state upscaling

  , TRANSPORT IN POROUS MEDIA, Vol: 71, Pages: 53-73, ISSN: 0169-3913
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  • Citations: 25
• Journal article
  saunders J, jackson M, pain C, 2008,

  Fluid flow monitoring in oilfields using downhole measurements of electrokinetic potential

  , Geophysics, Vol: 73, Pages: E165-E180

  Downhole measurements of electrokinetic potential are a promising new technology for hydrocarbon reservoir monitoring. Using a 3Dfinite-element model combining both multiphase flow and electrokinetic components, we investigated the behavior of electrokinetic (streaming) potential during oil production in a range of reservoir environments. We found that streaming-potential signals originate at fluid fronts and at geologic boundaries where fluid saturation changes. As water encroaches on an oil production well, the streaming-potential signal associated with the water front encompasses the well even when the front is up to 100 m away, so the potential measured at the well starts to change significantly relative to a distant reference electrode. Variations in the geometry of the encroaching water front can be characterized using an array of electrodes positioned along the well, but a good understanding of the local reservoir geology is required to identify signals caused by the front. The streaming potential measured at a well is maximized in low-permeability reservoirs produced at a high rate and in thick reservoirs with low shale content. However, considerable uncertainties remain, particularly relating to the nature of electrokinetic coupling at high salinity and during multiphase flow. Our results suggest that the streaming potential at low salinity (10^-3–10^-4 mol/L) is large (100–1000 mV) but might become too small to resolve (&lt;0.1) mV at high salinity (0.5–2 mol/L), depending on how the available data for the electrokinetic coupling at low salinity are extrapolated into the high-salinity domain. More work remains to determine the behavior of electrokinetic coupling and therefore the utility of this technique at high salinity.

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• Conference paper
  Addiego-Guevara EA, Jackson MD, Giddens MA, 2008,

  Insurance value of intelligent well technology against reservoir uncertainty

  , SPE/DOE Improved Oil Recovery Symposium
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• Journal article
  Jonoud S, Jackson MD, 2008,

  Validity of Steady-State Upscaling Techniques

  , SPE Reservoir Evaluation and Engineering, Vol: April, Pages: 405-416
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• Journal article
  Rushmer T, Jackson MD, 2008,

  Impact of melt segregation on tonalite–trondhjemite–granodiorite (TTG) petrogenesis

  , Trans. Royal Society of Edinburgh: Earth Science, Vol: 79, Pages: 325-336
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• Conference paper
  Choi K, Jackson MD, Hampson GJ, Jones A, Reynolds Tet al., 2007,

  Impact of heterogeneity on flow in fluvial-deltaic reservoirs: Implications for the giant ACG Field, south Caspian Basin (SPE 107137)

  , SPE Europec/EAGE Annual Conference, Publisher: Society of Petroleum Engineers paper 107137
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